CN111119815B - Method for determining production well production allocation ratio through balanced displacement - Google Patents
Method for determining production well production allocation ratio through balanced displacement Download PDFInfo
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- CN111119815B CN111119815B CN202010008564.5A CN202010008564A CN111119815B CN 111119815 B CN111119815 B CN 111119815B CN 202010008564 A CN202010008564 A CN 202010008564A CN 111119815 B CN111119815 B CN 111119815B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
Abstract
The invention relates to the technical field of oilfield development, in particular to a method for determining the production well allocation ratio by balanced displacement. The method comprises the following steps: step 1, determining the range of different injection-production well spacing; step 2, splitting the wave coverage range of the two production well groups in a linear one-injection mode; step 3, determining the remaining recoverable reserves in the range of the group spread of each injection-production well; and 4, determining the production allocation proportion of different production wells. The method can achieve the aims of finally balancing displacement and improving the recovery ratio.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a method for determining the production allocation ratio of a production well by balanced displacement.
Background
Due to the strong plane heterogeneity of the low-permeability reservoir, the water content difference is large, the plane displacement is unbalanced, the plane extraction degree difference is large, and residual oil in part of wells is enriched.
Balanced displacement means that the degree of displacement is the same in all directions of the formation. Actual reservoirs cannot achieve complete equilibrium displacement but only partial equilibrium displacement. If the displacement degrees in the connecting line direction of each injection and production well of the stratum are all equal, the displacement is called (partial) balanced displacement. Due to the influence of the difference of parameters such as injection-production well spacing, water content, plane physical properties and the like, plane equilibrium displacement is difficult to achieve. Through reasonable production allocation and injection allocation research, the maximum balanced displacement is realized, so that the oil field development effect is improved, and the recovery rate is finally improved.
The current research on the production allocation and injection allocation optimization of oil-water wells mainly comprises the following steps: liu de Hua and the like determine production parameters of each production well on a block by a grey prediction method, and then determine the reasonable injection amount of each water injection well according to an injection-production balance principle and an incidence matrix among the wells on the block (application of the Liu De Hua, Zhang Li Min. grey system method in oilfield development. system engineering, 1993; 11(4): 52-59); the plane split coefficient method is used for replacing the traditional KH method or H method for calculating the reasonable water distribution amount of a water injection well in the stone crowning canal and the like (stone crowning canal, Madao Xiang. research on the reasonable water distribution amount calculation method of the water injection well, western prospecting engineering, 2008; 9: 94-96); the method for improving the unbalance of the oil field development plane is provided (Qiubun attitude, Jingguo super, Dongkou, etc. the practice and application of injection and production structure adjustment in the late development stage of extra high water content of the double river oil field, Henan Petroleum, 2002; 16(2): 18-20); the relation between stratum pressure change and injection-production structure adjustment is obtained by numerical simulation by Zhao Chunshen et al, and the influence of the injection-production structure on the development effect is determined (Zhao Chunshen, Li Chenglong, Zhang Dan. research on the influence of the injection-production structure on the development effect is determined by using numerical simulation results.scientific technology and engineering, 2011; 11(34): 8577-8581). The technical scheme is that the method comprises the steps of providing a standard of balanced displacement in an extra-high water cut period by a person with a high intelligence transfer rate and the like aiming at the condition that one-injection two-production well group and two-injection one-production well group in a fault block oil reservoir are unbalanced in the two-injection production wells in the extra-high water cut period, developing the optimization research of production allocation and injection allocation of the well groups under the heterogeneous conditions of different reservoirs, and establishing a water injection amount or liquid amount distribution ratio chart for the balanced displacement of the two well groups in a given regulation and control time under the condition of different heterogeneous reservoirs. The research results are applied to the injection and production allocation of the actual well group, and a better development effect is achieved (the research on the allocation and injection optimization of the typical well group in the ultra-high water-cut period of the fault block oil reservoir [ J ] scientific technology and engineering, 2013(03): 159-.
At present, on-site test attempts are mainly carried out in qualitative aspects aiming at the problem, and the liquid production level of a production well is not quantitatively researched.
Disclosure of Invention
The invention aims to provide a method for determining the group sweep range of an injection well and a production well under the influence of multiple factors, and a method for determining the production allocation ratio of a production well by balanced displacement is designed on the basis of the method.
In order to realize the purpose, the invention adopts the following technical scheme: a method of determining a production well stimulation rate for balanced displacement comprising the steps of:
step 1, determining the distance wave and range of different injection and production wells;
step 2, splitting the wave range of the straight line one-injection two production well groups;
step 3, determining the remaining recoverable reserves in the range of the group spread of each injection-production well;
and 4, determining the liquid production level proportion of different production wells.
Preferably, in the step 1, the injection-production well distance range of the target block is counted, the particle motion trajectories at different injection-production well distances are obtained by using a streamline model, and the swept range of the different injection-production well distances is calculated by using a mathematical method;
preferably, a conceptual model is established to obtain a streamline distribution diagram with different injection-production well distances, the streamline sweep range can be simplified into two elliptic nested mathematical graphs, and the area of the graph is the sweep range of one injection-production well group;
preferably, the interval between different injection-production well intervals is 50-100 m.
Preferably, L is calculated CO 、L HB And L FG Three parameters, wherein L CO The maximum swept distance, L, in the vertical direction of the midpoint of the injection-production well connecting line HB The maximum swept distance, L, of the injection well point along the vertical direction of the injection-production well connecting line FG The injection well extends for the maximum distance along the connecting line of the injection well and the production well; and summarizing the change rule of the three parameters along with the injection-production well spacing, regressing an equation, and calculating the wave combination range of one injection and one production under the condition of different injection-production well spacing.
Preferably, in step 2, the injection-production well groups for two-production are injected in a straight line, and the swept range of each injection-production well group is split mathematically in the common swept range around the injection well.
Preferably, the common swept area may be approximated by two circular regions.
Preferably, in step 3, the remaining recoverable reserves of each injection and production well group are obtained according to the water content condition of the production well and the flow splitting curve obtained by combining the oil-water relative permeability.
Preferably, the method for obtaining the residual recoverable reserves of each injection and production well group comprises the following steps:
drawing a flow distribution curve: by utilizing a water phase split flow formula and combining relative permeability data, the water contents under different water saturation degrees, namely a water phase split flow curve can be obtained;
preferably, the aqueous phase split flow formula is:
in the formula (f) w Water content, K ro Different water saturation S w Relative permeability of the oil phase, K rw Different water saturation S w Relative permeability of the aqueous phase,. mu. w Water viscosity at formation conditions, μ o Viscosity of crude oil at formation conditions, S w -water saturation;
secondly, calculating the saturation of the remaining oil which can be extracted,
S yor ＝1-S fw -S or
in the formula, S yor -recoverable residual oil saturation; s. the or -residual oil saturation; s. the fw -water saturation under current water conditions;
calculating the residual recoverable reserve of each injection-production well group
Wherein i ═ 1,2, S' i Area of sweep range, m, of injection-production well group i 2 ；h i -average effective thickness, m, of the injection and production well group i; phi represents the average porosity and decimal of the injection-production well group; ρ is a unit of a gradient o Ground crude oil density, kg/m 3 ；B o -crude oil volume factor, dimensionless quantity;
-recoverable residual oil saturation for injection-production well group i.
Preferably, in step 4, the liquid production level proportion of the production wells of each injection and production well group is determined by combining the water content condition of each production well with the aim that the residual recoverable amount of each injection and production well group is completely displaced at the same time.
Preferably, the production well of the injection-production well group has a production fluid level ratio of:
the method is established by aiming at the straight-line one-injection two-production well group, considering the difference of water content, injection and production well spacing and the like, and adjusting the production liquid level of the production well so as to achieve the aim of finally balancing displacement. And (3) counting the range of the injection-production well distance according to the target area, obtaining particle motion tracks at different injection-production well distances by using a streamline model, and calculating the sweep range of the different injection-production well distances by using a mathematical method. For the injection-production well group with one injection and two production in straight line, the common sweep range around the injection well is split into the sweep ranges of the injection-production well groups by a mathematical method. And obtaining a flow dividing curve according to the relative permeability of oil and water, and obtaining the residual recoverable reserves of each injection and production well group by combining the water content condition of the production well. And determining the liquid production level proportion of the production wells of each injection and production well group by taking the aim that the residual recoverable reserves of each injection and production well group are completely displaced at the same time and combining the water-containing conditions of each production well.
The invention comprehensively considers the water content change condition brought by various factors such as heterogeneity, process measures, pump detection and the like, can adjust the liquid preparation proportion of the production well in real time, is convenient for on-site calculation operation, and ensures that the maximum balanced displacement can be finally realized.
Drawings
Fig. 1 is a schematic view of a flow line model according to an embodiment of the present invention.
Fig. 2 is a simplified schematic diagram of a beam-injection-production well group sweep range according to an embodiment of the present invention.
Fig. 3 is a simplified schematic diagram of a linear one-injection two-production well group sweep range according to an embodiment of the present invention.
FIG. 4 is a plot of the aqueous phase split flow in an embodiment of the invention.
Detailed Description
It is to be understood that the following detailed description is exemplary and is intended to provide further explanation of the invention as claimed. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the invention. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of the stated features, steps, operations, and/or combinations thereof, unless the context clearly indicates otherwise.
In order to make the technical solutions of the present invention more clearly understood by those skilled in the art, the technical solutions of the present invention will be described in detail below with reference to specific embodiments.
Embodiment of the method for determining the production well production allocation ratio by balanced displacement
In this embodiment, taking a low permeability reservoir of a victory oil field as an example, the method includes the following steps:
step 1, counting the injection and production well spacing of the low-permeability reservoir of the victory oil field, wherein the injection and production well spacing of the oil field is generally 200-500m, establishing a conceptual model to obtain a streamline distribution diagram (figure 1) with different injection and production well spacings (100 m), wherein the streamline sweep range can be simplified into two elliptic nested mathematical graphs (figure 2), and the area of the graphs is the sweep range of one injection-production well group.
In the flow profile, 3 key parameters can be measured for different injection-production well spacing (table 1), namely: l is a radical of an alcohol CO 、L HB And L FG (L CO Is the maximum swept distance, L, in the vertical direction of the midpoint of the injection-production well connecting line HB The maximum swept distance, L, of the injection well point along the vertical direction of the injection-production well connecting line FG The injection well extends a maximum distance along the injection-production well connection).
TABLE 1 statistical table of key parameters of different injection-production well intervals
And summarizing the change rule of the 3 key parameters along with the injection-production well spacing, and regressing an equation.
L CO ＝0.39L AB -10
L HB ＝0.0003L AB 2 +0.067L AB +21.8
L FG ＝-0.0002L AB 2 +0.296L AB -28.1
Area of a wave range of a group of injection and production wells:
in step 2, the two injection and production well groups are injected linearly, the common swept area can be approximated to two circular areas (fig. 3), and the swept area areas of the two injection and production well groups can be respectively calculated.
And one injection and two production well groups are linearly arranged, and injection and production well distances of 300m and 400m are taken as examples.
And (3) carrying out injection and extraction at the well spacing of 300m into a regression formula of key parameters to obtain:
area of wave coverage range of injection-production well group at 300m well spacing:
firstly, injecting and extracting 400m well spacing, and substituting a regression formula of key parameters to obtain:
the area of the sweep range of the injection-production well group with the well spacing of 400m in the first injection-production process:
the common swept area of the first injection well and the second production well is as follows:
area of the group sweep range of 300m injection-production wells:
the area of the group sweep range of the injection-production well with the length of 400m is as follows:
in the step 3, a flow splitting curve is obtained by utilizing the relative permeability of oil and water, the water saturation of the production well point at the moment is obtained according to the water-containing condition, the oil saturation is obtained, and the recoverable residual oil saturation is obtained by combining the movable oil saturation. And (3) according to the sweep range of the 2 injection-production well groups calculated in the step (2), combining the counted geological parameters of the injection-production well groups to obtain the recoverable reserves of the injection-production well groups.
Drawing a flow dividing curve
The water content calculation formula is as follows:
since the relative permeability ratio of oil and water phases is expressed as a function of water saturation, i.e.:
obtaining:
referred to as the aqueous phase split flow equation, in combination with the relative permeability numberAccordingly, different water saturation levels S can be obtained w Lower water content f w I.e. the aqueous phase split flow curve.
The aqueous phase split flow curves are shown in figure 4.
② calculating the saturation of the recoverable residual oil
The water saturation for different water cut conditions can be obtained from figure 4.
The water content of the production well is respectively as follows:
the water saturation can be obtained according to the split flow curve.
The water saturation of the production well is respectively as follows:
the saturation of the recoverable residual oil at the injection-production well spacing is calculated as follows:
calculating the residual recoverable reserve of each injection-production well group
The average effective thicknesses of the two injection and production well groups are counted as follows:
h 1 ＝8(m)，h 2 ＝6(m)。
the remaining recoverable reserves of the two injection-production well groups are respectively as follows:
in the formula, phi represents the average porosity and decimal of the injection-production well group; rho o Ground crude oil density, kg/m 3 ；B o Crude oil volume factor, dimensionless quantity.
And 4, determining the liquid production level proportion of the production wells of each injection and production well group by combining the water content condition of each production well with the aim that the residual recoverable reserves of each injection and production well group are completely displaced at the same time.
Time required for the injection-production well group to be completely displaced:
in the formula, h i -average effective thickness, m, of each injection-production well group; phi is the average porosity of the injection and production well group, decimal; ρ is a unit of a gradient o Ground crude oil density, kg/m 3 ；
The injection and production well group is completely displaced at the same time, t 1 ＝t 2 I.e. by
Obtaining:
namely the determined liquid production level proportion of the production wells of the injection-production well group.
In conclusion, the invention comprehensively considers the water content change condition caused by various factors such as heterogeneity, process measures, pump detection and the like, can adjust the liquid preparation proportion of the production well in real time, is convenient for on-site calculation operation, and ensures that the maximum balanced displacement can be finally realized.
The above embodiments are preferred embodiments of the present invention, but the present invention is not limited to the above embodiments, and any other changes, modifications, substitutions, combinations, and simplifications which do not depart from the spirit and principle of the present invention should be construed as equivalents thereof, and all such modifications are intended to be included in the scope of the present invention.
Claims (1)
1. A method of determining a productive well allocation ratio for balanced displacement, the method comprising:
step 1, determining the range of different injection-production well spacing;
step 2, splitting the wave coverage range of the two production well groups in a linear one-injection mode;
step 3, determining the remaining recoverable reserves in the group sweep range of each injection-production well;
step 4, determining the liquid production horizontal proportion of different production wells;
in the step 1, the injection-production well distance range of the target block is counted, particle motion tracks of different injection-production well distances are obtained by using a streamline model, and a well group sweep range is calculated by using a mathematical method; or establishing a conceptual model to obtain a streamline distribution diagram with different injection-production well distances, simplifying a streamline sweep range into two elliptic nested mathematical graphs, and setting the area of the graphs as a well group sweep range;
the interval of the different injection-production well distances is 50-100 m;
in the step 2, linearly injecting and extracting injection and production well groups for two times, and splitting the swept range of each injection and production well group by a mathematical method in the common swept range around the injection well; the common sweep range is approximately two circular areas;
in step 3, according to the water content condition of the production well, combining with a flow splitting curve obtained by oil-water relative permeability to obtain the residual recoverable reserves of each injection-production well group;
the method for obtaining the residual recoverable reserves of each injection-production well group comprises the following steps:
firstly, a flow rate curve is drawn: obtaining water contents under different water saturations by utilizing a water phase flow splitting formula and combining relative permeability data, namely obtaining a water phase flow splitting curve;
the water phase flow rate formula is as follows:
in the formula, f w Water content, K ro Different water saturation S w Relative permeability of the oil phase, K rw Different water saturation S w Relative permeability of the aqueous phase,. mu. w Water viscosity, μ, at formation conditions o Viscosity of crude oil at formation conditions, S w -water saturation;
secondly, calculating the saturation of the remaining oil which can be extracted,
S yor ＝1-S fw -S or
in the formula, S yor -recoverable residual oil saturation; s or -residual oil saturation; s fw -water saturation under current water conditions;
calculating the residual recoverable reserve of each injection-production well group
Wherein, i is 1,2,
-remaining recoverable reserves of injection and production well group i; s' i Spread area, m, of injection-production well group i 2 ；h i -average effective thickness, m, of the injection and production well group i; phi represents the average porosity and decimal of the injection-production well group; rho o Ground crude oil density, kg/m 3 ；B o -crude oil volume factor, dimensionless quantity;
-recoverable residual oil saturation for injection-production well group i;
determining the horizontal liquid production proportion of the production wells of each injection and production well group by taking the aim that the residual recoverable reserves of each injection and production well group are completely displaced at the same time and combining the water-containing conditions of each production well;
in step 4, the liquid production level proportion of the production wells of the injection-production well group is as follows:
in the formula (I), the compound is shown in the specification,
-production fluid levels of the production wells of the two injection and production well groups;
-water cut, decimal, of the production wells of both well groups.
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| CN114575801B (en) * | 2020-12-01 | 2024-03-01 | 中国石油天然气集团有限公司 | Method and device for optimizing liquid amount of water flooding injection and production well based on streamline simulation |
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Inventor after: Cao Xiaopeng Inventor after: Li Jiaxiang Inventor after: Chen Hui Inventor after: Zhang Shiming Inventor after: Ren Yunpeng Inventor after: Sun Du Inventor after: Jia Yanping Inventor after: Sun Xiuzhi Inventor after: Li Chao Inventor after: Liu Zupeng Inventor before: Chen Hui Inventor before: Li Jiaxiang Inventor before: Zhang Shiming Inventor before: Cao Xiaopeng Inventor before: Ren Yunpeng Inventor before: Sun Du Inventor before: Jia Yanping Inventor before: Sun Xiuzhi Inventor before: Li Chao Inventor before: Liu Zupeng |
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